Permanent well completion apparatus



May 26, 1959 G. H. 'rAuscH ET A1.

PERNANEN'A`4 WELL COMPLETION APPARATUS Filed Dec. 13, 195'? illllilllllllililllllivlfilllilllnvll il!!! Iflllf /AAA/ FIG. 3.

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f'"v l G. 2 INvENToRs. GILBERT H. TAUSCH,

CHARLES B. CORLEYJR., JOHN W. KENNEDAY,

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r A SEEE n ATTORNEY.

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United States Patent PERMANENT WELL COMPLETION APPARATUS Gilbert H. Tausch, Charles B. Corley, Jr., and John W.

Kenneday, Houston, Tex., assignors, by mesne assignments, to Jersey Production Research Company, Tulsa,

kla., a corporation of Delaware Application December 13, 1957, Serial No. 702,706 4 claims. (ci. 16s- 192) This invention is directed to permanent well completion apparatus for producing, working over and servicing a plurality of hydrocarbon productive intervals. More particularly, the invention is directed to a plugging tool especially adaptable for use in permanent well completion operations.

In permanent well completion operations, tubing strings are set permanently during the life of the well and various producing, workover, and servicing operations are performed through these permanently set tubing strings. The workover and servicing operations generally performed on permanently completed wells include squeeze cementing operations wherein existing perforations below the lower end of the tubing are cemented ofi; perforating or reperforating operations by means of wire line tools at the same or different producing zones or intervals; sand washing operations; acidizing operations.; and other remedial work. A full discussion of permanent well completion operations -appears in Permanent Type Completion and Wire Line Workovers, The Petroleum Engineer, September 195 6. The retrievable plugging tool of the invention may be employed in operations of this nature. For example, it may be used to plug oi the well bore between two productive zones in a manner describedy later herein.

Referring to the drawings: v

Fig. 1 is a cross-section of a well bore showing the devicel of the invention employed with one type of Apermanent well completion apparatus for working over an upper productive interval arranged therein;

Fig. 2 is a vertical, sectional view of the plugging tool adapted for use in the arrangement of apparatus of Fig. 1 showing the tool in one position; and

l Fig. 3 is a vertical, sectional view illustrating the ging tool of Fig. 2 in another position.

Referring more particularly to the drawings wherein identical numerals designate identical parts:

' Fig. 1 shows a borehole 10 penetrating a plurality of productive intervals 11 vand 12. A casing 13 extends through productive intervals 11 and 12 and is cemented therein by means of cement 14. A single bore casing packer 15 is positioned in the well bore between upper and lower productive intervals 11 and 12. A dual bore casing packer 20 is positioned in the well bore above the uppermost productive interval 11. Dual well head equipment, not shown, is positioned at the surface of the earth and has connected thereto two parallelly extending, eccentric, tubing strings 23 and 24 which are permanently set in the well according to permanent well 'completion practices. Tubing strings23 and 24 may be the same size butare preferably of dilerent dimensions, as shown, in order that various rates of' production may be more efficiently controlled. These tubing strings are set in the well bore with the dualpacker 20 positioned adjacent their lower open ends which seals off the space or annulus A between the tubing strings and casing 13. Packer 20 is provided with a laterally extending passageway 25, which uidly communicates the lower open end of tubing plusice string 24 and the lower open end of tubing string 23. The latter tubing string is provided with a landing nipple 26 which may be of any desirable type for supporting a tubular extension member such as the landing nipple described in the Composite Catalog, vol. 1, 52-53, 19th ed. page 4063. Tubing string 23 is provided with an opening 32 above the upper packer 20, which opening iiuidly communicates annulus A and the interior of tubing string 23. A tubular extension 35 is provided with anchoring means 36 -and packing 37, 38, 39, and 40. Extension 35 is connected to a plug member, generally designated 41 and more clearly seen in Figs. 2 and 3 to be described. Plug member 41 is provided with openings 43, which openings tluidly communicate production yzone 11 and the interior of tubular extension 35.

In the operation for working over the upper zone, uid, such as cement, may be injected into tubing string 23 from the earths surface; the fluid injected flows downwardly through tubular extension 35 and out openings 43 to adjacent interval 11. The circulation of fluid is accomplished by the luid passing upwardly through the annulus 44 into laterally extending passage 25 and thence upwardly through the tubing string 24 to the earths surface. Reverse circulation is eitected by flowing 4fluid downwardly through tubing string 24 through passage 25, openings 43 and upwardly through tubular extension 35 and tubing string 23.

Plugging tool 41, as seen in Figs. 2 and 3, includes a mandrel 50 having arranged thereon spaced-apart upper and. lower chevron packings 39 and 40, respectively. Mandrel 5@ is formed to provide an opening 48 uidly communicating the interior and exterior of the mandrel. A. no-go ring 55 having a diameter greater than the d ameter of the bore of packer 15 but less than the diameter of -tubing string 23 is arranged on the upper end of mandrel 50 and functions to prevent mandrel 50 from passing through the bore of packer 15. A tubular member 56 formed of screw threadedly connected sections is movably arranged in and extends through mandrel 50. The tubular member is formed to provide circulation ports 43 arranged above mandrel 50, an opening 58 vlocated in is in the position shown in Fig. 2. When tubular member 56 is in the position shown in Fig. 3, sealing means 63 is above mandrel 50 and is not in sealing engagement therewith. Also sealing means 64 is not in sealing engagement with tubular member 56, when tubular member 56 is in the position shown in Fig. 3, ybecause slot 5I formed in tubular member 56 by-passes sealing means 64. A shear pin 77 releasably interconnects mandrel 50 and tubular member 56.

A plurality of teeth 70 are formed on tubular member 56.v A sleeve 71 is slidably arranged on the outer sur-i face of tubular member 56 and is provided with a split finger grab 72, which is adapted to engage with teeth 70. Sleeve 71 is provided with an internal surface'73 adjacenty opening 43 in tubular member 56. A frangible pin 74 releasably secures sleeve 71 in the closed position (Fig. 2). A sealing means 75 is arranged on the in-` terior surface of sleeve 71 and is adapted to seal off the space between tubular member 56 and slidable sleeve 71 above opening 43. Also a sealing means 76 is arranged on tubular member S6 and is adapted to seal off,lv 4the space between slidable sleeve 71 and tubular member assenso 56 below opening 43 when the sleeve is in the closed position.

Thus, when sleeve 71 is in the closed position, fluid communication through opening 43 is prevented Whereas when sleeve 71 is in the open position (Fig. 3) uid communication is permitted through opening 43.

When the apparatus is in operative position, packing 39 and sealing means 63 and 64 may be tested by applying fluid pressure through tubular extension 35. Tubular member 56 and slidable sleeve 71 are in their Fig. 2 positions at this time and accordingly the fluid pressure passes through tubular member56, through opening 5 8 in tubular member 56 and opening 48 in mandrel 50. Any leakage of packing 39 or sealing means 63 and 64 will be evidenced by fluid in tubing string 24 or apressure drop in tubular extension 35. Packer 38 adjacent upper packer 20 may be pressure tested by applying uidpressure through tubing 24 wherein fluid in annulus lA evidences leakage. Slidable sleeve 71 remains in its lower or Fig. 2 position during this operation. Thus, circulating ports 43 do not at this time iluidly communicate the interior and exterior of tubular member 56.

When it is desired to treat the upper zone 11, additional, selected, iluid pressure of a treating iluid, such as cement, within tubular member 56 acts upon the surface 73 of slidable member 71. This force fractures shear pin 74 and moves slidable sleeve 71 upwardly. The split Ylinger grab 72 engages teeth 70 and locks slidable sleeve 71 in the upper position/shown in Fig. 3. Treating operations may thenbeconducted by circulating uidthrough circulating ports 43.

When treating operations have been completed' and it is desired'to remove tubular extension 35 from the well bore, a suitable wire line tool is lowered to engage with the fishing head of tubular extension 35. Then, upward force applied to the wire line moves tubular extension 35 and connected plugging tool 41 upwardly. If thev frictional forces restraining packing 39 and 40 aresutciently large or if the lhydrostatic pressure acting downwardly against mandrel 50 is suiciently large to prevent upward movement of mandrel 50 then upward movement of tubular extension 35 causes shear pin 77 to fracture which permits tubular member 56 to move upwardly relative to mandrel 50. Upward movement of tubular member 56 equalizes the pressures above and below packer because sealing means 63 moves out of sealing engagement with mandrel 50 and by means of by-pass 51 tubular member 56 moves out of engagement with sealing means 64 as seen in Fig. 3. Thus, the spaces above and below packer 15 are in uid communication through the annulus between tubular member 56 and mandrel S0. It s desirable to provide such uid communication since the pressure below mandrel 50 may be less than the pressure above mandrel 50 and within tubular member 56 thereby requiring application of greater force to remove the plugging tool than would otherwise be necessary. Therefore, it is desirable to first equalize pressures above and below mandrel 50. Further upward movement of tubular member 56 causes shoulder 59 of tubular member 56 to engage the lower end of mandrel 50. Upon engagement thereof removal of the tubular extension 35 removes connected tubular member 56 and engaged mandrel 50.

Thus, the plugging tool permits testing of the lower packing and permits retrieving of the lower packing prior to lthe hardening of any cement or plastic used in the we For illustrative purposes the use of the plugging tool has been shown and described in conjunction with a particular arrangement of permanent well completion apparatus. However, since its used with other types of apparatus is contemplated with scope of the invention is not to be considered limited thereto.

Having fully described the nature, objects, elements and operation of our invention, we claim:

1. A retrievable plugging tool adapted to plug the bore of a packer comprising a mandrel extensible through said packer bore, said mandrel being provided with an opening intermediate the length thereof; spaced-apart rst sealing means arranged on said mandrel adapted to seal ol the annulus between said mandrel and said packer bore wall above and below said mandrel opening; a tubular member having rst and second positions slidably arranged in said mandrel and adapted to be connected to a tubing, said tubular member being provided with a lower closed end, a shoulder, spaced-apart first and second openings, and a bore, said bore providing a passageway in uid communication with saidrst and second openings; said tubular member first opening uidly communicating with said mandrel opening when said tubular member is in said rst position; upper and lower spaced-apart second sealing means adapted to seal off the annulus between said tubular member and said mandrel above and below said mandrel opening when said tubular member is in said first position; by-pass means provided on said tubular member adapted to fluidly communicate said tubular member-mandrel annulus above and below said lower second sealing means when said tubular member is in said second position, said lupper second sealing means being positioned above saidy mandrel when said tubular member is in said second position whereby pressures are equalized above and below said packer when said tubular member is in said second position; first frangible means releasably interconnecting said tubular member and said mandrel when said tubular member is in said iirst,l position; a hydraulically movable sleeve having firstandsecond positions arranged on said tubular member adapted to close oi said tubular member second opening when. said sleeve is in said iirst position and adapted to permit fluid communication through said tubular member second opening when said sleeve is in said second position; second frangible means intercounecting said sleeve and saidv tubular member adapted to releasablysecure said sleeve in said rst position; locking means arranged on said sleeve and said tubular member cooperating to lock said sleeve in said second position; spaced-apart third sealing means adapted to sealol the space between said sleeve and said tubular member above and below said tubular member second opening when said sleeve is in said rst position; stop means arranged on said mandrel above. said packer adapted to prevent movement of said mandrel through said packer bore; said shoulder being adapted to engagedly connect with the lower end of said mandrel for removing said plugging tool from said packer bore upon fracture of said first frangible means and movement of said tubular member upwardly to said second position thereof.

2. A retrievable plugging tool adapted to plug the bore y of a packer comprising a mandrel extensible through said packer bore, said mandrel being provided with an opening intermediate the length thereof; spaced-apart rst sealing means arranged on said mandrel adapted to seal offthe annulus between said mandrel and said packer bore wall above and below said mandrel opening; a member having.

rst and second positions slidably arranged in said mandrel and adapted to be connected to a tubing, said member being provided with a lower closed end, spaced-apart first and second openings, anda passageway fluidly cornmunicating the interior of said tubing and said first andA second openings; said member first opening uidly communicating with said mandrel opening when said member is in said rst position; upper and lower spaced-apart second sealing means adapted to seal off the space between said member and said mandrel above and below said mandrel opening when said member is in said first position; said member being provided with means adapted to fluidly communicate the space between said member and said mandrel above and below said lower second sealing means when said member is in said second position, said upper second sealing means being above said mandrel when said member is in said second position whereby pressures are equalized above and below said packer when said member is in said second position; means releasably interconnecting said member and said mandrel adapted to releasably secure said member in said rst position; hydraulically movable means having first and second positions arranged on said member adapted to close oil said member second opening when in said iirst position and adapted to permit fluid communication through said member second opening when in said second position; means releasably interconnecting said movable means and said member; means arranged on said movable means and said member cooperating to lock said movable means in said second position; spaced-apart third sealing means adapted to seal olf the space between said movable means and said member above and below said member second opening when said movable means is in said first position; means arranged on said mandrel above said packer adapted to prevent movement of said mandrel through said packer bore; and means adapted to engagedly connect with the lower end of said mandrel for removing said plugging tool from said packer bore.

3. A retrievable plugging tool comprising a mandrel; a tubular member having lirst and second positions slidably arranged in said mandrel and adapted to be connected to a tubing, said tubular member being provided with a lower closed end, an opening, and a bore, said bore providing a passageway uidly communicating said opening and the interior of said tubing; upper and lower spaced-apart sealing means adapted to seal olf the annulus between said tubular member and said mandrel when said tubular member is in said rst position; by-pass means formed on said tubular member adapted to fluidly communicate said tubular member-mandrel annulus above and below said lower sealing means when said tubular member is in said second position; said upper sealing means being positioned above said mandrel when said tubular member is in said second position whereby iluid communication above and below said mandrel is etected when said tubular member is in said second position; rst frangible means interconnecting said tubular member and said mandrel when said tubular member is in said rst position adapted to releasably secure said tubular member to said mandrel; a hydraulically movable sleeve having irst and second positions arranged on said tubular member adapted to close off said tubular member opening when in said rst position and adapted to permit fluid communication through said opening when in said second position; second frangible means interconnecting said sleeve and said tubular member adapted to releasably secure said sleeve in said first position; locking means arranged on said sleeve and said tubular member cooperating to lock said sleeve in said second position; and additional spaced-apart sealing means adapted to seal oli the space between said sleeve and said tubular member above and below said tubular member opening when said sleeve is in said rst position.

4. A retrievable plugging tool comprising a mandrel; a member having irst and second positions slidably a.rranged in said mandrel and adapted to be connected to a tubing, said member being provided with a lower closed end, an opening, and a passageway iluidly communicating said opening and the interior of said tubing; upper and lower sealing means adapted to seal oi the space between said member and said mandrel when said member is in said first position; means provided on said member adapted to fluidly communicate the space between said member and said mandrel above and below said lower sealing means when said member is in said second position, said upper sealing means being above said mandrel when said member is in said second position whereby fluid communication above and below said mandrel is eected when said member is in said second position; means releasably interconnecting said member and said mandrel securing said member in said rst position; hydraulically movable means having first and second positions arranged on said member adapted to close olf said opening when in said tirst position and adapted to permit fluid communication through said opening when in said second position; means releasably interconnecting said movable means and said member securing said movable means in said rst position; means arranged on said movable means and said member cooperating to lock said movable means in said second position; and additional spaced-apart sealing means adapted to seal oit the space between said movable means and said member above and below said member opening when said movable means is in said first position.

References Cited in the le of this patent UNITED STATES PATENTS 2,606,616 Otis Aug. 12, 1952 2,722,279 Collins Nov. 1, 1955 2,726,724 Wilhoit et al Dec. 13, 1955 2,822,048 Tausch Feb. 4, 1958 

